Layer | Fill | Outline |
---|
Map layers
Theme | Visible | Selectable | Appearance | Zoom Range (now: 0) |
---|
Fill | Stroke |
---|---|
Collaborating Authors
Search planning: production test
...minimal infrastructure exists to service wells with rigs. Wells are initially completed with 4-1/2" production tubing. This paper covers the following scope: - Predict when wells may need artificial lift Scr...mmend artificial lift strategy The particular challenges in this field are as follows: - Limited production history 4-1/2" limitation in which to install smaller tubulars - Potential for water encroachment... - Reservoir continuity uncertainty - Potential for unconsolidated sand production - - 10-13% CO 2 in the produced gas Table 1--Well and Field Properties Table 2--Initial Ra...
...SPE-206936-MS Planning the Production Lifecycle of a Newly Developed Gas Field in a Remote Desert Steven Hochanadel, Bagus Wahyu Setiadi... The objective of this paper is to present an analysis and methodology to forecast individual well production in a new, developing channel sand gas reservoir complex. The paper predicts when liquid loading may... occur, specifies a strategy for changing production tubing sizes, and selects the types of artificial lift that may be required in the future. The appr...
...ssure and for an additional field compression 200 psig WHP case. Since it is difficult early in the production history of the field to predict how the wells will decline, this paper will use 20% and 30% effecti...ated cases of possible water influx as some wells have a clearly defined water zone beneath the gas production zone. Critical Rates The critical rates to lift water in a well by Turner et al. (1969) are shown...purpose, including Coleman's model or liquid film reversal model. Liquid loading may start when the production of a well falls below this critical rate. This will lead to lower and fluctuating flow conditions, ...
Abstract The objective of this paper is to present an analysis and methodology to forecast individual well production in a new, developing channel sand gas reservoir complex. The paper predicts when liquid loading may occur, specifies a strategy for changing production tubing sizes, and selects the types of artificial lift that may be required in the future. The approach of this paper is to forecast production rates using a combination of decline curves and vertical lift performance (VLP) curves. Liquid loading is projected to occur when the gas production rate of a well reaches the Turner critical flow rate in the existing production tubing size and expected wellhead pressure. Artificial lift methods are identified using an artificial lift type screening matrix based on the production parameters after liquid loading occurs. Artificial lift methods are also examined for a scenario of increased water production if water encroachment occurs in a well. Not all wells decline at the same rate due to the nature of the sand channels. Some wells will reach a critical rate faster than others. Once a critical rate is reached in a well, the first step to maintain the flow will be to install smaller internal diameter production tubing. As production continues to decline, liquid loading will occur again in the smaller tubulars. At this point, artificial lift will be necessary to extend well life to the economic limit. The primary focus then becomes gas well deliquification using plunger lift or foam lift. For the water encroachment scenario, plunger lift or foam lift will not suffice; instead, the artificial lift methods of rod pump, gas lift, or hydraulic jet pump apply. However, a feasibility assessment will need to be made to determine whether the lift methods are economic. This paper presents a methodology to plan for the production lifecycle of a gas field from the outset. It provides some insight on when to plan for procurement and installation of smaller internal diameter tubulars in a remote desert area where workover rigs are not present. Further, the methodology allows some assurance that artificial lift methods will be ready to implement when needed to maximize recovery.
- Asia > Middle East (0.46)
- North America > United States (0.28)
...-54121-MS. http://dx.doi.org/10.2118/54121-MS * Carmona, R. and Decoster, S.A.E. 2001. Assessing Production Potential of Heavy Oil Reservoirs From the Orinoco Belt with NMR Logs. Presented at the SPWLA Annua...MS. http://dx.doi.org/10.2118/63258-MS * Minh, C.C., Bordon, E., Hurliman, M. et al. 2005. Field Test Results of the New Combinable Magnetic Resonance Autotune Logging Tool. Presented at the SPE Annual...
In some complex reservoirs, low-resistivity/low-contrast pay, low-porosity/low-permeability, and medium-to-heavy oil,nuclear magnetic resonance (NMR) log data--independently or in combination with other log data--provide the best and/or only means of accurate formation and fluid evaluation. Because NMR-log data acquisition is complex, job preplanning is essential to ensure optimal selection of acquisition parameters that will result in reliable and accurate data and in the maximum information possible in any given reservoir and logging environment. A clear understanding of the logging job objectives is necessary for optimizing the NMR acquisition parameters to best achieve these objectives.[1][2][3][4] This process must take place before the actual logging. Heavy oil and tar sands * 2.2 Wettability * 2.3 Borehole rugosity * 2.4 Mud type * 2.5 Metal debris * 2.6 Logging speed and running average * 2.7 Vertical resolution * 3 Nomenclature * 4 References * 5 Noteworthy papers in OnePetro * 6 External links * 7 See also Typical preplanning consists of three steps: * Define the need for NMR measurements * Collect all available borehole (e.g., diameter, mud, salinity, and temperature) and reservoir (e.g., formation and fluid properties) information needed to assess the expected NMR responses in the zone of interest, and understand what can and cannot be resolved with NMR * Select the appropriate tool (on the basis of operational considerations, borehole size, and condition) and acquisition type (i.e., determining the appropriate acquisition parameters, data resolution, and logging speed) that will provide maximum answers for a given job[1] Although the actual in-situ reservoir characteristics may be unknown, estimates of the anticipated fluid properties, based on available information such as reports for nearby wells or fields, are used to define and optimize an acquisition sequence that will provide the data needed to meet the job objectives.
- North America > United States (1.00)
- Europe (0.70)
- Asia > Middle East > Israel > Mediterranean Sea (0.24)
- Geology > Petroleum Play Type > Unconventional Play > Heavy Oil Play (1.00)
- Geology > Rock Type > Sedimentary Rock (0.71)
- Information Technology > Knowledge Management (0.40)
- Information Technology > Communications > Collaboration (0.40)